3 rd QUARTER 2019 EARNINGS November 5 th , 2019 IMPORTANT - - PowerPoint PPT Presentation

3 rd quarter 2019 earnings
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3 rd QUARTER 2019 EARNINGS November 5 th , 2019 IMPORTANT - - PowerPoint PPT Presentation

3 rd QUARTER 2019 EARNINGS November 5 th , 2019 IMPORTANT DISCLOSURES No Offer or Solicitation Communications herein do not constitute an offer to sell or the solicitation of an offer to buy any securities or a solicitation of any vote or


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SLIDE 1

3rd QUARTER 2019 EARNINGS

November 5th, 2019

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SLIDE 2

IMPORTANT DISCLOSURES

No Offer or Solicitation Communications herein do not constitute an offer to sell or the solicitation of an offer to buy any securities or a solicitation of any vote or approval with respect to the proposed transaction or otherwise, nor shall there be any sale of securities in any jurisdiction in which such offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such jurisdiction. Communication herein do not constitute a notice of redemption with respect to or an offer to purchase or sell (or the solicitation of an offer to purchase or sell) any preferred stock of Carrizo Oil & Gas, Inc. Additional Information and Where to Find It In connection with the proposed transaction, Callon has filed, and the SEC has declared effective, a registration statement on Form S-4 (the “Registration Statement”), which contains a joint proxy statement of Callon and Carrizo that also constitutes a prospectus of Callon. This communication is not a substitute for the joint proxy statement/prospectus or the Registration Statement or for any other document that Callon or Carrizo may file with the SEC and/or send to Callon’s shareholders and/or Carrizo’s shareholders in connection with the proposed transaction. INVESTORS AND SECURITY HOLDERS OF CALLON AND CARRIZO ARE URGED TO READ THE REGISTRATION STATEMENT AND JOINT PROXY STATEMENT/PROSPECTUS, AS EACH MAY BE AMENDED OR SUPPLEMENTED FROM TIME TO TIME, AND OTHER RELEVANT DOCUMENTS FILED BY CALLON AND CARRIZO WITH THE SEC CAREFULLY WHEN THEY BECOME AVAILABLE BECAUSE THEY WILL CONTAIN IMPORTANT INFORMATION ABOUT CALLON, CARRIZO AND THE PROPOSED TRANSACTION. Investors will be able to obtain free copies of the Registration Statement and joint proxy statement/prospectus, as each may be amended from time to time, and other relevant documents filed by Callon and Carrizo with the SEC (when they become available) through the website maintained by the SEC at www.sec.gov. Copies of documents filed with the SEC by Callon will be available free of charge from Callon’s website at www.callon.com under the “Investors” tab or by contacting Callon’s Investor Relations Department at (281) 589- 5200 or IR@callon.com. Copies of documents filed with the SEC by Carrizo will be available free of charge from Carrizo’s website at www.carrizo.com under the “Investor Relations” tab

  • r by contacting Carrizo’s Investor Relations Department at (713) 328-1055 or IR@carrizo.com.

Participants in the Proxy Solicitation Callon, Carrizo and their respective directors and certain of their executive officers and other members of management and employees may be deemed, under SEC rules, to be participants in the solicitation of proxies from Callon’s shareholders and Carrizo’s shareholders in connection with the proposed transaction. Information regarding the executive officers and directors of Callon is included in its definitive proxy statement for its 2019 annual meeting filed with the SEC on March 27, 2019. Information regarding the executive officers and directors of Carrizo is included in its definitive proxy statement for its 2019 annual meeting filed with the SEC on April 2, 2019. Additional information regarding the persons who may be deemed participants and their direct and indirect interests, by security holdings or otherwise, will be set forth in the Registration Statement and joint proxy statement/prospectus and

  • ther materials when they are filed with the SEC in connection with the proposed transaction. Free copies of these documents may be obtained as described in the paragraphs above.

Cautionary Statement Regarding Forward-Looking Information Certain statements in this communication concerning the proposed transaction, including any statements regarding the expected timetable for completing the proposed Carrizo transaction, the results, effects, benefits and synergies of the proposed transaction, future opportunities for the combined company, future financial performance and condition, guidance and any other statements regarding Callon’s or Carrizo’s future expectations, beliefs, plans, objectives, financial conditions, assumptions or future events or performance that are not historical facts are “forward-looking” statements based on assumptions currently believed to be valid. Forward-looking statements are all statements other than statements of historical facts. The words “anticipate,” “believe,” “ensure,” “expect,” “if,” “intend,” “estimate,” “probable,” “project,” “forecasts,” “predict,” “outlook,” “aim,” “will,” “could,” “should,” “would,” “potential,” “may,” “might,” “anticipate,” “likely” “plan,” “positioned,” “strategy,” and similar expressions or other words of similar meaning, and the negatives thereof, are intended to identify forward-looking statements. The forward-looking statements are intended to be subject to the safe harbor provided by Section 27A of the Securities Act of 1933, Section 21E of the Securities Exchange Act of 1934 and the Private Securities Litigation Reform Act of 1995. These forward-looking statements involve significant risks and uncertainties that could cause actual results to differ materially from those anticipated, including, but not limited to, failure to obtain the required votes of Callon’s shareholders or Carrizo’s shareholders to approve the transaction and related matters; whether any redemption of Carrizo’s preferred stock will be necessary or will occur prior to the closing of the transaction; the risk that a condition to closing of the proposed transaction may not be satisfied, that either party may terminate the merger agreement or that the closing of the proposed transaction might be delayed or not occur at all; potential adverse reactions or changes to business or employee relationships, including those resulting from the announcement or completion of the transaction; the diversion of management time on transaction-related issues; the ultimate timing, outcome and 2

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SLIDE 3

IMPORTANT DISCLOSURES (CONTINUED)

results of integrating the operations of Callon and Carrizo; the effects of the business combination of Callon and Carrizo, including the combined company’s future financial condition, results of operations, strategy and plans; the ability of the combined company to realize anticipated synergies in the timeframe expected or at all; changes in capital markets and the ability of the combined company to finance operations in the manner expected; regulatory approval of the transaction; the effects of commodity prices; and the risks of oil and gas

  • activities. Expectations regarding business outlook, including changes in revenue, pricing, capital expenditures, cash flow generation, strategies for our operations, oil and natural gas

market conditions, legal, economic and regulatory conditions, and environmental matters are only forecasts regarding these matters. Additional factors that could cause results to differ materially from those described above can be found in Callon’s Annual Report on Form 10-K for the year ended December 31, 2018 and in its subsequent Quarterly Reports on Form 10-Q for the quarter ended March 31, 2019, and the quarter ended June 30, 2019, each of which is on file with the SEC and available from Callon’s website at www.callon.com under the “Investors” tab, and in other documents Callon files with the SEC, and in Carrizo’s Annual Report on Form 10-K for the year ended December 31, 2018 and in its subsequent Quarterly Reports on Form 10-Q for the quarter ended March 31, 2019, and the quarter ended June 30, 2019, each of which is on file with the SEC and available from Carrizo’s website at www.carrizo.com under the “Investor Relations” tab, and in other documents Carrizo files with the SEC. All forward-looking statements speak only as of the date they are made and are based on information available at that time. Neither Callon nor Carrizo assumes any obligation to update forward-looking statements to reflect circumstances or events that occur after the date the forward-looking statements were made or to reflect the occurrence of unanticipated events except as required by federal securities laws. As forward-looking statements involve significant risks and uncertainties, caution should be exercised against placing undue reliance on such statements. Supplemental Non-GAAP Financial Measures This presentation includes non-GAAP measures, such as Adjusted EBITDA, Net Debt to LQA Adjusted EBITDA, Total Liquidity, Free Cash Flow and other measures identified as non-

  • GAAP. Reconciliations are available in the Appendix.

EBITDA is a supplemental non-GAAP financial measure that is used by management and external users of our financial statements, such as industry analysts, investors, lenders and rating agencies. We define EBITDA as net income (loss) before interest expense, income taxes, depreciation, depletion and amortization, asset retirement obligation accretion expense, (gains) losses on derivative instruments excluding net settled derivative instruments, impairment of oil and natural gas properties, non-cash equity based compensation and other

  • perating expenses. Management believes EBITDA is useful because it allows it to more effectively evaluate our operating performance and compare the results of our operations from

period to period and against our peers without regard to our financing methods or capital structure. We exclude the items listed above from net income in arriving at EBITDA because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. EBITDA should not be considered as an alternative to, or more meaningful than, net income as determined in accordance with GAAP or as an indicator of our operating performance or liquidity. Certain items excluded from EBITDA are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are components of EBITDA. Our presentation of EBITDA should not be construed as an inference that our results will be unaffected by unusual or non-recurring items. Net Debt to Last Quarter Annualized (“LQA”) Adjusted EBITDA is a non-GAAP measure. The Company defines Net Debt to LQA Adjusted EBITDA as the sum of total long-term debt less unrestricted cash and cash equivalents (as determined under U.S. GAAP), divided by the Company’s current quarter annualized Adjusted EBITDA inclusive of pro-forma results from its disposition completed in the current period. The Company presents these metrics to help evaluate its capital structure, financial leverage, and forward-looking cash profile. The Company believes that that these metrics are widely used by industry professionals, research and credit analysts, and lending and rating agencies in the evaluation of total leverage. Free Cash Flow is a supplemental non-GAAP financial measure that is used by management and external users of our financial statements to assess our liquidity. We define free cash flow as net cash provided by operating activities before changes in working capital less capital expenditures (inclusive of operational capital expenditures, seismic, leasehold and other expenditures, as well as capitalized general and administrative expense and capitalized interest expense). Management believes that free cash flow provides useful information in assessing the impact of our ability to generate cash flow in excess of capital requirements and to return cash to shareholders. Free cash flow should not be considered an alternative to net cash provided by operating activities or any other GAAP measures. We have not provided a reconciliation of projected free cash flow to projected net cash provided by operating activities and capital expenditures used in net cash provided by investing activities, the most comparable financial measures calculated in accordance with GAAP. We are unable to project net cash provided by operating activities for any future period because such metric includes the impact of changes in operating assets and liabilities related to the timing of cash receipts and disbursements that may not relate to the period in which the operating activities occurred. We are unable to project these timing differences with any reasonable degree of accuracy without unreasonable efforts such as predicting the timing of our and our customers' payments, with accuracy to a specific day, months in advance. 3

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SLIDE 4

CALLON CORPORATE STRATEGY

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THE EVOLUTION FROM CORE ASSETS TO A SUSTAINABLE OPERATING BUSINESS MODEL

  • 1. Slide from Callon February 2019 investor presentation deck.

Core Permian Footprint Established

2014 - 2018

Evolving to Full Field Development 2019

▪ Increased Permian position from ~19,000 to ~85,000 net acres in core areas ▪ Ramped activity from 2 to 5 rigs and increased net lateral footage drilled ▪ Built out robust infrastructure network (>$200 mm invested) ▪ Increased credit facility from $250 million to $1.1 billion ▪ Expanded Callon skill sets with significant investments in employee base ▪ Added cash flow per debt- adjusted share to compensation metrics ▪ Harvest asset value through increasing pad development and cycle time reductions ▪ Optimize margins and increase

  • perational flexibility

▪ Thoughtful capital allocation to minimize outspend while growing at a measured rate to augment sustainable corporate return model ▪ Balance longer term reinvestment

  • pportunities with near-term

return profile ▪ Selective activity to “block up” acreage, extend laterals, and increase working and mineral interests

Sustainable Growth and FCF Generation 2020 +

▪ Sustainable double-digit organic growth funded with internally generated cash flow ▪ Large pad development, benefiting resource optimization and long-term corporate level returns ▪ Leading cash margin preservation through cost management and leveraging of existing infrastructure ▪ Select asset rationalization

  • pportunities to enhance returns
  • n capital

▪ Accelerate capital efficiency with balanced growth and maturing decline profile

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SLIDE 5

DELIVERING SUPERIOR RESULTS AND CAPITAL EFFICIENCY

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YoY FINANCIAL ACHIEVEMENTS

  • 1. 3Q18 adjusted for Delaware asset acquisition and Ranger divestiture.
  • 2. Net Debt to LQA Adjusted EBITDA is a non-GAAP measure and is calculated as the sum of total long-term debt less unrestricted cash and cash equivalents (as determined under U.S. GAAP), divided by the Company’s

current quarter annualized Adjusted EBITDA. Please refer to the Appendix for reconciliation.

  • 3. Based on Bloomberg consensus estimates as of 10/18/19.
  • 4. Adjusted EBITDA is a non-GAAP financial measure; please refer to the Important Disclosures for a definition on Adjusted EBITDA as calculated by Callon and the Appendix for reconciliation.

153 166 150 160 170 180 3Q18 3Q19 DAILY PRODUCTION PER SHARE (Boepd/MM) (1) $5.84 $5.65 $5.50 $5.75 $6.00 3Q18 3Q19 LEASE OPERATING EXPENSE ($/Boe) (1) 2.5x 2.5x 2.0x 2.5x 3.0x 3Q18 3Q19 LEVERAGE (NET DEBT / LQA

  • ADJ. EBITDA) (1)(2)

OPERATIONAL HIGHLIGHTS ▪ Increased capital efficiency with transition to larger pad development ▪ Improved uptime, reduced LOE, and mitigated operational risk through completion of Southern Delaware optimized integration project ▪ Increased ESP run time, chemical savings, and water recycling drove operating costs lower sequentially

3Q19 CONSENSUS (3) 3Q19 ACTUAL TOTAL PRODUCTION (Mboepd) 37.2 37.8

  • ADJ. EBITDA (4)

($MM) $111 $117 TOTAL CAPEX + CAPITALIZED ITEMS ($MM) $143 $143 LOE ($/Boe) $6.02 $5.65 $1.4 $1.2 $1.0 $1.2 $0.8 $1.2 $1.6 CPE: 2018 CPE: 2019 CPE: Recent SIMOPs Offset Operator Average D&C ($MM) /1,000’

3Q DELAWARE DRILLING AND COMPLETION REDUCTIONS 3Q MIDLAND DRILLING AND COMPLETION REDUCTIONS

$1.1 $0.9 $0.6 $0.8 $0.5 $0.9 $1.3 CPE: 2018 CPE: 2019 CPE: Recent Large Project Offset Operator Average D&C ($MM) /1,000’

B2 B1 3Q18 3Q19 MOODY’S LONG TERM CREDIT RATING

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SLIDE 6

DELAWARE: EARLY TIME RAG RUN PERFORMANCE DELAWARE: OPTIMIZED LARGE PAD FLOWBACK

6

UNLOCKING VALUE THROUGH SCALED DEVELOPMENT

PERMIAN: HIGHLIGHTING LARGE PROJECT TRANSITION MIDLAND: LARGE PAD WELLS OUTPERFORMING

▪ Scale

▪ Leveraging location and supporting equipment costs across larger production base ▪ Efficiently utilizing water recycling and overall infrastructure

▪ Continuous operations

▪ Accelerated drill time learning curve with recent 2019 Delaware wells averaging < 30 days vs. 38 days in 2018 ▪ Pump time reductions achieved record breaking 15 stages per day for recent 7 well co-development project in Midland

▪ Optimal project size balances IRR and NPV of wells by section

▪ Mega Pad development reduces number of child wells per section ▪ Fewer child wells improves production uptime (and revenue) while preserving NAV of undeveloped inventory 100 200 300 400 500 600 6 Well SIMOPs Cumulative Mboe 90 Day Average Well Production: ~ 1,000 Boepd (~80% Oil) 20 40 60 80 100 120 Average Well Cumulative Oil Production (MBo) Normalized 10,000' Lateral

WCA Direct Parent Offset (2015-2017) WCA 7 Well Co-Develop Project (2019) WCA 5 Well Pad (2019)

Days on production Days on production 0 10 20 30 40 50 60 70 80 90 4 8 25 30 35 2017 2018 1H19 Recent SIMOPs Average Project Size (# of wells) Average 30 Day Choke Size Average Choke Size Average Project Size (# of wells) 0 30 60 90 120 150 180

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SLIDE 7

RISK MANAGEMENT COMPLEMENTS STRONG FUNDAMENTAL MARGINS

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HEDGE PROGRAM SECURES CASH RETURN

5,000 10,000 15,000 20,000 25,000 30,000 4Q19 2020 Total Volumes Hedged (Excluding Brent and Basis Hedges) Oil (Bbls/d) Natural Gas (MMBtu/d)

BEST IN CLASS MARGINS OFFER DIFFERENTIATED AND SUSTAINABLE RETURNS (1)(2) MARKETING DIVERSIFIES PRICE EXPOSURE

NYMEX Floor $58.56 NYMEX Floor $55.63

  • 1. Adjusted EBITDA is a non-GAAP financial measure; please refer to the Important Disclosures for a definition on Adjusted EBITDA as calculated by Callon and the Appendix for reconciliation.
  • 2. Bloomberg data sourced for consensus EBITDA, consensus production estimate, actual production, and actual adjusted EBITDA. Peers include: CDEV, FANG, LPI, MTDR, OAS, PE, PDCE, WPX.

NYMEX Floor $3.07 NYMEX Floor $2.49

$20 $25 $30 $35 $40 3Q17 4Q17 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19 3Q19 Adjusted EBITDA Margin ($/Boe) CPE Actual CPE Consensus Peer Average Actual Peer Average Consensus 5 10 15 20 25 30 35 40 45 1Q20 1Q20 3Q20 2Q21 Gross CPE Volumes Linked to MEH/International Pricing (Mb/d)

2Q21: ~ 40 mb/d gross CPE Permian volumes linked to MEH/International Pricing

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SLIDE 8

CONSISTENT FOCUS ON FINANCIAL OBJECTIVES

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1. Cash Return on Invested Capital (“CROCI”) is defined as (GAAP cash flow from operations before changes in working capital + after tax interest expense) / (average total debt + average stockholders’ equity).

  • Ongoing compensation alignment with shareholder interests
  • Retain best-in-class margins
  • Reduce capital intensity of business

INCREASE CASH RETURN ON INVESTED CAPITAL (1)

  • Consistent measured growth in development moderates PDP

declines

  • 2019 trajectory improves with capital efficiency
  • Generate Free Cash Flow in 2020

GENERATE FREE CASH FLOW

  • Target leverage < 2.0x through organic FCF and absolute

debt reduction

  • Non-core monetizations
  • Continued capital discipline

REDUCE LEVERAGE

  • Sustainable co-development of organic inventory
  • Balance IRR and NPV for optimal full cycle returns
  • Marketing diversification mitigates pricing concentration risk

and adds upside

LONG TERM FOCUS

ACHIEVED BY MERGER WITH CARRIZO?

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SLIDE 9

PREMIER OPERATOR WITH STRONG INTEGRATION TRACK RECORD

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1.. Sourced from Drilling Info with wells drilled and completed by operator. Represents P50 distribution of average well performance by each operator for Wolfcamp A wells brought online in the Southern Delaware from 2017-current and have at least 6 months of publicly available production data. See Appendix for further breakdown.

  • 2. Callon wells: 5 / Cimarex wells: 9.
  • 3. Net operated Delaware production data based on Callon operated wells, excludes producing wells acquired from Ameredev and Cimarex.

PREMIER SOUTHERN DELAWARE OPERATOR (1)

10 11 12 13 14 15 Previous Operator Average WCA Well CPE Average WCA Well Average 6 Month Lateral Adjusted Cumulative Bo

HISTORIC COST REDUCTIONS AND OPERATED PRODUCTION GROWTH FOLLOWING ACQUISITION INTEGRATION (3) IMPROVED PERFORMANCE FROM 2018 WARD ACQUISITION

2,000 4,000 6,000 8,000 10,000 12,000 $4.50 $5.00 $5.50 $6.00 $6.50 $7.00 $7.50 1Q17 2Q17 3Q17 4Q17 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19 3Q19 Net Incremental Delaware Operated Production (Boepd) Lease Operating Expense ($/Boe) Net Incremental Delaware Operated Production (Boepd) Lease Operating Expense ($/Boe)

2/13/17: Ameredev Acquisition Closes 8/31/18: Ward County Bolt-On Closes 2,000 4,000 6,000 8,000 10,000 12,000 14,000 16,000 18,000 20,000 Average 6 Month Cumulative Boe (20:1 Conversion)

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SLIDE 10

CRZO ACQUISITION: STRONGER COMBINED COMPANY

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  • 1. CPE and CRZO production reported as two stream and three stream, respectively. No financial impact from using two stream vs. three stream reporting.
  • 2. Free cash flow calculated as cash flow from operations less capex, capitalized G&A, capitalized interest, preferred dividends, contingency payments and transaction costs. Includes $72.5mm of G&A and operational

synergies in 2020. Assumes pricing $55/bbl and $2.75mcf.

EAGLE FORD PERMIAN - DELAWARE PERMIAN - MIDLAND

2020E Capital Allocation: ~50% 2020E Capital Allocation: ~25% 2020E Capital Allocation: ~25%

~200,000 Net Acres Over 100,000 Boepd

2x >17 >105

Core Delaware Basin Footprint Years Permian Inventory Mboed Production (2Q19) (1)

~$100MM

Incremental Free Cash Flow in 2020 (2)

<2.0x

Target Leverage by Year-End 2020

~$50

$ / Barrel Corporate 2020 Free Cash Flow Breakeven, Down from $55 Standalone

>10% Production CAGR through 2021 >15% Cash Return on Capital Invested by

2020

>$100MM

Annual Synergies by 2021 (70% by 2020)

+7%

Accretive to NAV per Share

>$1.2B

Q2 2019 Annualized EBITDA

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SLIDE 11

Corporate G&A savings Delaware D&C cost savings Improved Permian production uptime Annual run rate synergies

SIGNIFICANT AND ACHIEVABLE SYNERGIES TO BENEFIT STAKEHOLDERS

Note: Synergies based on 7/11/2019 NYMEX strip pricing through 2023 with prices held flat thereafter and Wall Street consensus pricing through 2021 with prices held flat thereafter; synergies do not change materially at current strip.

  • 1. Includes capitalized G&A, historically ~20% of all-in cash G&A.

ANNUAL RUN RATE OPERATIONAL SYNERGIES (2021+) ($MM)

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NPV OF $2 PER CALLON SHARE REPRESENTS ~50% OF CALLON’S CURRENT SHARE PRICE

10 YR TOTAL (OPERATIONAL AND CAPITAL) NPV OF SYNERGIES ($MM)

Corporate Cash G&A Reductions ▪ ~50% of Carrizo 2019E all-in cash G&A¹ Delaware Drilling and Completion Cost Savings ▪ 5 - 8% reduction in Delaware drilling and completion / ft ▪ Expanded large scale development with simultaneous

  • perations improves

production cycle times and well costs Improved Permian Uptime ▪ 2020 target of 1% increase in Permian field production uptime ▪ Large projects minimize impact on adjacent producing wells

~$650MM NPV

$250 $400 $200

Total synergies

Optimized Capital Allocation ▪ Larger cash flow base allows for near-term activity acceleration ▪ Blended portfolio of shorter cycle projects generates cash flow funding longer cycle projects driving NAV ▪ High-graded, long- term, multi-zone co- development program of two robust asset bases ▪ Optimized, integrated development schedule enhances efficiency

~$850MM NPV

$35-$45 $45-$65 $20 $100-$130 2020 Expected Synergies ~$35mm ~$25mm - $30mm

$2.00 $0.59

~$10mm ~$70-$75mm $850

$ / Callon share $0.94 $0.47 Optimized capital allocation Corporate G&A savings Operational synergies

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SLIDE 12

With the capital base of the combined company, two distinct sources of synergies become available

MEGA-PAD STRATEGY IMPROVES PERMIAN UPTIME

  • During completion of new wells, nearby wells are shut-in

Lost production during shut-in

Additional time and cost (dewatering) required to restore production

  • More wells per project results in less shut-ins, dewatering, and greater

production

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SCALED DEVELOPMENT UNLOCKS VALUE FOR COMBINED COMPANY

SIMULTANEOUS OPERATIONS IMPROVE COST EFFICIENCY

TBU Visual on D&C Reduction from larger pads – any osprey Data?

  • Multiple rigs / frac crews focused on a single project in a distinct location

More efficient utilization of drilling and completion crews; lowers capital cost per well

Enables sharing of fixed costs, leverages infrastructure and location prep

  • Callon completed its first Delaware SIMOPS 6-well mega-pad (Rag Run) in

July 2019: Baseline Multi-Well Pad (Wally World) SIMOPS Mega-Pad (Rag Run) Total Cost Per Well Capital Required ~$24 mm ~$60 mm Wells Completed 2 6 Cost / Well ~$12 mm ~$10 mm Drilling and Completion Costs Drilling $ / FT $556 $445 Completion $ / FT $682 $575 D&C $ / FT $1,238 $1,020 Lower cost / well despite longer laterals 18% lower D&C cost / FT (synergy targets based

  • n 5-8%)

Pad 1 (DSU A) Pad 2 (DSU A) Pad 3 (DSU A) Pad 1 (DSU B) Pad 2 (DSU B) Project 1 (DSU A) Project 2 (DSU B) Project 3 (DSU C)

Mega-Pad Strategy Reduces/Eliminates Shut-Ins Production Lost During Shut-in of Completed Wells CPE $0 $300 $600 $900 CRZO Delaware Only SIMOPS Program Midpoint of 2019 Guidance

Operational CapEx ($mm)

Scale development is a capital issue, not an acreage issue

  • Standalone, neither Callon nor Carrizo could afford the capital program

that would unlock value from a scaled, consistent development model

  • Synergies do not depend on additional adjacent acreage, nor on longer

laterals (average Delaware lateral > 8,500 feet)

– Callon will continue to pursue those opportunities as well – Current contiguous footprints allow for leveraging of facilities

Year 1 Annualized % Shut-In: > 1% Year 2+ Annualized % Shut-In: >2 % No Volumes Shut-In for Offset Completions

Mega-Pad 1 Mega-Pad 2 Mega-Pad 3

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SLIDE 13

MANAGEMENT FOCUSED ON FINANCIAL STRENGTH

13

KEY CORPORATE PRINCIPLES

  • 1. Free cash flow calculation is inclusive of interest expense, dividends, capitalized G&A, capitalized interest, contingency payments and transaction expenses.

HIGHLIGHTS

Upgraded by Moody’s to B1 with stable outlook and placed on CreditWatch Positive by S&P (current corporate credit rating of B)

Forecast corporate-wide FCF in 4Q19 with CRZO acquisition offering an accelerated path to FCF in 2020 and corresponding debt reduction

CRZO acquisition enhances opportunistic refinancing flexibility to reduce cost of capital over time

Announced $300 - $400 MM in targeted asset monetizations to improve leverage ratios and reduce absolute debt

Generate Sustainable Free Cash Flow Growth Reduce Leverage to < 2.0x Maintain Strong Liquidity Position Prudent Financial and Physical Risk Management Preserve Top-Tier Operating Margins

PRO FORMA CORPORATE FREE CASH FLOW BREAKEVEN PRO FORMA SENIOR NOTES MATURITY

< $50 ~ $60 ~ $50

2019E 2020 Target 2021 Target $0 $250 $500 $750 2020 2021 2022 2023 2024 2025 2026

> $300MM in 2020/2021 (1) Combined free cash flow generation accelerates leverage reduction and improves flexibility

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SLIDE 14

EXECUTING OUR STRATEGY

14

  • 1. Bloomberg data sourced for consensus EBITDA, consensus production estimate, actual production, and actual adjusted EBITDA. Peers include: CDEV, FANG, LPI, MTDR, OAS, PE, PDCE, WPX.
  • 2. Adjusted EBITDA is a non-GAAP financial measure; please refer to the Important Disclosures for a definition on Adjusted EBITDA as calculated by Callon and the Appendix for reconciliation.
  • 3. Free cash flow, is a non-GAAP financial measure . We define free cash flow as net cash provided by operating activities before changes in working capital less capital expenditures (inclusive of operational capital

expenditures, seismic, leasehold and other expenditures, as well as capitalized general and administrative expense and capitalized interest expense)

  • 4. Cash Return on Invested Capital (“CROCI”) is defined as (GAAP cash flow from operations before changes in working capital + after tax interest expense) / (average total debt + average stockholders’ equity).
  • Driving capital efficiency gains through sustained high levels of well

productivity coupled with emerging capital cost reductions from scaled development

  • Beat consensus estimates for EBITDA/Boe by an average of 5% over the last

nine quarters vs. peers averaging below consensus estimates (1)(2)

  • Retained peer-leading margins while successfully integrating new assets

through operating cost efficiency

SUPERIOR EXECUTION

  • Announced accretive CRZO acquisition which accelerates Free Cash Flow
  • bjectives and reduces corporate FCF breakeven costs to cost of supply (3)
  • Closed Southern Midland divestiture, advances value for tail-end inventory
  • Invested in water recycling expansion, mineral leasehold, and lateral

extensions for improved return on capital across the portfolio

ONGOING PORTFOLIO OPTIMIZATION

  • Lowered cost of capital through Preferred stock redemption
  • Advanced risk management initiatives with additional hedging and offtake

agreements

  • Continued to evolve compensation philosophy with changing landscape,

with addition of CROCI metric (4)

  • Launched Sustainability website, reiterating commitment to responsible

value creation and stewardship

SUSTAINABILITY

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SLIDE 15

APPENDIX

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SLIDE 16

1.7 x < 2.0 x 2.0 x 2.4 x 2.4 x 2.5 x

BBB Median CPE Pro Forma Target BB Median CRZO Current B Median CPE Current

16

CARRIZO ACQUISITION IS CREDIT ENHANCING

CURRENT NET DEBT / 2019E EBITDA YE 2018 PROVED RESERVES (MMBOE)

Note: BBB-rated E&Ps include APA, CLR, CXO, DVN, ECA, HES, MRO, NBL, OXY, PXD, XEC. BB-rated E&Ps include AKER, AR, CNX, FANG, MUR, PDCE, PE, RRC, SM, SWN, WLL, WPX. B-rated E&Ps include BRY, CDEV, CHK, CRK, GPOR, HPR, JAG, LPI, MGY, MTDR, OAS, QEP, TALO, XOG. ¹ Net Debt to LQA Adjusted EBITDA is a non-GAAP measure and is calculated as the sum of total long-term debt less unrestricted cash and cash equivalents (as determined under U.S. GAAP), divided by the Company’s current quarter annualized Adjusted EBITDA inclusive of pro-forma results from its disposition completed in the current period. ² Proved reserves data pro forma for CPE’s recent Southern Midland divestiture.

POSITIVE COMMENTARY FROM CREDIT AGENCIES

SCALE AND FREE CASH FLOW ENHANCING TRANSACTION IS A CREDIT POSITIVE FROM RATINGS PERSPECTIVE

“Callon announced a transaction to acquire Carrizo Oil & Gas Inc (B1 stable) in an all-stock transaction that the company expects to close in 2019. This acquisition will be credit positive for Callon.”

  • Moody’s, October 24, 2019

2019E EBITDA ($MM)

1 1

2

“The CreditWatch positive placement reflects our expectation that the acquisition of Carrizo will materially improve the scale, scope, and diversity of Callon's business. It also reflects our belief that the company's credit measures will remain adequate and begin to improve in 2020 as it integrates the acquisition… The CreditWatch placement reflects that we would likely raise

  • ur issuer credit rating on Callon by one notch to 'B+' following the close of

the Carrizo acquisition.”

  • S&P, July 16, 2019

1,281 921 540 329 250 211 BBB Median BB Median CPE Pro Forma CRZO Standalone B Median CPE Standalone 3,190 1,275 1,216 746 603 470 BBB Median BB Median CPE Pro Forma CRZO LQA B Median CPE LQA

slide-17
SLIDE 17

LEADING SOUTHERN DELAWARE WELL PERFORMANCE (1)

17

SOUTHERN DELAWARE WCA WELLS ACROSS PEERS

  • 1. Source: All well data sourced from drilling info with wells drilled and completed by operator.
  • 2. P50 represents the average well performance by each operator for Wolfcamp A wells brought online in the Southern Delaware from 2017-current and have at least 6 months of publicly available production data.

WCA RESULTS BY OPERATOR (2017+) (2)

0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% Well Count and Production Distribution Plot P(x) Average 6 Month Cumulative Production Boe (20:1 Oil Gas Conversion)

2,000 4,000 6,000 8,000 10,000 12,000 14,000 16,000 18,000 20,000 Peer 1 Peer 2 CRZO CPE Peer 3 Peer 4 Peer 5 Peer 6 Peer 7 Peer 8 Peer 9 Peer 10 Peer 11 Average 6 Month Cumulative Boe (20:1 Conversion)

CPE CRZO

slide-18
SLIDE 18

HEDGE PORTFOLIO (1)

18

1. Hedge contracts as of 10/17/19.

4Q19 1Q20 2Q20 3Q20 4Q20 FY 2020 FY 2021 WTI NYMEX (Bbls, $/Bbl) Swaps & Swaps with Puts Total Volumes 276,000 546,000 546,000 552,000 552,000 2,196,000

  • Total Daily Volumes

3,000 6,000 6,000 6,000 6,000 6,000

  • Avg. Sw ap

$60.17 $56.06 $56.06 $56.06 $56.06 $56.06

  • Avg. Short Put Price
  • $42.50

$42.50 $42.50 $42.50 $42.50

  • Three-way Collars

Total Volumes 1,196,000 1,274,000 1,274,000 1,288,000 1,288,000 5,124,000

  • Total Daily Volumes

13,000 14,000 14,000 14,000 14,000 14,000

  • Avg. Short Call Price

$67.46 $65.46 $65.46 $65.46 $65.46 $65.46

  • Avg. Long Put Price

$56.54 $55.45 $55.45 $55.45 $55.45 $55.45

  • Avg. Short Put Price

$43.65 $44.66 $44.66 $44.66 $44.66 $44.66

  • Avg. Premium Price

($0.09) $0.21 $0.21 $0.21 $0.21 $0.21

  • Two-way Collars

Total Volumes 276,000

  • Total Daily Volumes

3,000

  • Avg. Short Call

$60.00

  • Avg. Put

$55.00

  • Put Options

Total Volumes 230,000

  • Total Daily Volumes

2,500

  • Avg. Long Put Price

$65.00

  • Avg. Premium Price

$6.44

  • Put Spreads

Total Volumes 230,000

  • Total Daily Volumes

2,500

  • Avg. Long Put Price

$65.00

  • Avg. Short Put Price

$42.50

  • Avg. Premium Price

$4.39

  • Total Volume Hedged (Bbl)

2,208,000 1,820,000 1,820,000 1,840,000 1,840,000 7,320,000

  • Average Ceiling Price ($/Bbl)

$65.13 $62.64 $62.64 $62.64 $62.64 $62.64

  • Average Floor Price ($/Bbl)

$58.56 $55.63 $55.63 $55.63 $55.63 $55.63

  • ICE BRENT (Bbls, $/Bbl)

Three-way Collars Total Volumes

  • 150,000

227,500 230,000 230,000 837,500

  • Total Daily Volumes
  • 1,648

2,500 2,500 2,500 2,288

  • Avg. Short Call Price
  • $70.00

$70.00 $70.00 $70.00 $70.00

  • Avg. Long Put Price
  • $58.24

$58.24 $58.24 $58.24 $58.24

  • Avg. Short Put Price
  • $50.00

$50.00 $50.00 $50.00 $50.00

slide-19
SLIDE 19

HEDGE PORTFOLIO (1)

19

1. Hedge contracts as of 10/17/19.

4Q19 1Q20 2Q20 3Q20 4Q20 FY 2020 FY 2021 MIDLAND-CUSHING DIFFERENTIAL (Bbls/$/Bbl) Swaps Total Volumes 2,176,000 1,092,000 1,092,000 1,196,000 1,196,000 4,576,000 1,095,000 Total Daily Volumes 23,652 12,000 12,000 13,000 13,000 12,503 3,000

  • Avg. Sw ap Price

($2.50) ($1.73) ($1.73) ($0.89) ($0.89) ($1.29) $1.00 MAGELLAN EAST HOUSTON DIFFERENTIAL (Bbls/$/Bbl) Swaps Total Volumes

  • 192,000

291,201 440,802 515,202 1,439,205

  • Total Daily Volumes
  • 2,110

3,200 4,791 5,600 3,932

  • Avg. Sw ap Price
  • $2.40

$2.40 $2.40 $2.40 $2.40

  • NYMEX HENRY HUB (MMBtu, $/MMBtu)

Swaps Total Volumes 155,000 910,000 910,000 920,000 920,000 3,660,000

  • Total Daily Volumes

1,685 10,000 10,000 10,000 10,000 10,000

  • Avg. Sw ap Price

$2.87 $2.48 $2.48 $2.48 $2.48 $2.48

  • Three-way Collars

Total Volumes

  • 910,000

910,000 920,000 920,000 3,660,000

  • Total Daily Volumes
  • 10,000

10,000 10,000 10,000 10,000

  • Avg. Short Call Price
  • $2.75

$2.75 $2.75 $2.75 $2.75

  • Avg. Long Put Price
  • $2.50

$2.50 $2.50 $2.50 $2.50

  • Avg. Short Put Price
  • $2.00

$2.00 $2.00 $2.00 $2.00 Two-way Collars Total Volumes 598,000

  • Total Daily Volumes

6,500

  • Avg. Short Call Price

$3.50

  • Avg. Put Price

$3.13

  • Total Volume Hedged (MMBtu)

753,000 1,820,000 1,820,000 1,840,000 1,840,000 7,320,000

  • Average Ceiling Price ($/MMBtu)

$3.37 $2.61 $2.61 $2.61 $2.61 $2.61

  • Average Floor Price ($/MMBtu)

$3.07 $2.49 $2.49 $2.49 $2.49 $2.49

  • WAHA DIFFERENTIAL (MMBtu, $/MMBtu)

Swaps Total Volumes 2,116,000 2,093,000 1,183,000 2,116,000 2,116,000 7,508,000

  • Total Daily Volumes

23,000 23,000 13,000 23,000 23,000 20,514

  • Avg. Sw ap Price

($1.18) ($1.15) ($1.12) ($1.15) ($1.15) ($1.14)

slide-20
SLIDE 20

QUARTERLY CASH FLOW STATEMENT

20

3Q18 4Q18 1Q19 2Q19 3Q19 Cash flows from operating activities: Net income (loss) $ 37,931 $ 156,194 $ (19,543) $ 55,180 $ 55,834 Adjustments to reconcile net income to cash provided by operating activities: Depreciation, depletion and amortization 48,977 60,301 60,672 64,374 57,107 Accretion expense 202 248 241 216 128 Amortization of non-cash debt related items 708 734 738 741 739 Deferred income tax (benefit) expense 1,487 5,647 (5,149) 16,691 17,902 (Gain) loss on derivatives, net of settlements 25,100 (105,512) 66,970 (15,193) (20,798) (Gain) loss on sale of other property and equipment (102) (64) 28 21 (13) Non-cash expense related to equity share-based awards 1,708 1,823 4,545 1,754 1,569 Change in the fair value of liability share-based awards 879 (1,053) 1,881 (850) (925) Payments to settle asset retirement obligations (507) (389) (664) (107) (654) Payments for cash-settled restricted stock unit awards

  • (1,296)

(129)

  • Changes in current assets and liabilities:

Accounts receivable (56,764) 37,033 (5,390) 44,071 (21,081) Other current assets 3,885 (5,936) (2,294) (3,807) 929 Current liabilities 47,741 9,510 (26,003) (10,251) 23,216 Other 4,791 (6,897) (177) (2,224) (261) Net cash provided by operating activities 116,036 151,639 74,559 150,487 113,692 Cash flows from investing activities: Capital expenditures (156,982) (155,821) (193,211) (166,219) (143,995) Acquisitions (550,592) (122,809) (27,947) (11,423) (1,418) Acquisition deposit 27,600

  • Proceeds from sales of assets

5,249 683 13,879 260,417 5,656 Additions to other assets

  • (3,100)
  • Net cash provided by (used in) investing activities

(674,725) (281,047) (207,279) 82,775 (139,757) Cash flows from financing activities: Borrowings on senior secured revolving credit facility 105,000 230,000 220,000 140,000 221,000 Payments on senior secured revolving credit facility (40,000) (95,000) (90,000) (365,000) (126,000) Payment of deferred financing costs (1,296) 530

  • (31)

Issuance of common stock 7 (376)

  • Payment of preferred stock dividends

(1,823) (1,824) (1,824) (1,823) (350) Tax withholdings related to restricted stock units (216)

  • (1,025)

(833) (316) Redemption of preferred stock

  • (5)

(73,012) Net cash provided by (used in) financing activities 61,672 133,330 127,151 (227,692) 21,322 Net change in cash and cash equivalents (497,017) 3,922 (5,569) 5,570 (4,743) Balance, beginning of period 509,146 12,129 16,051 10,482 16,052 Balance, end of period $ 12,129 $ 16,051 $ 10,482 $ 16,052 $ 11,309

slide-21
SLIDE 21

NON-GAAP RECONCILIATION (1)

21

  • 1. See “Important Disclosure” slides for disclosures related to Supplemental Non-GAAP Financial Measures.

Adjusted EBITDA Reconciliation 3Q18 4Q18 1Q19 2Q19 3Q19 Net income (loss) $ 37,931 $ 156,194 $ (19,543) $ 55,180 $ 55,834 (Gain) loss on derivatives, net of settlements 25,100 (105,512) 66,970 (15,193) (20,798) Non-cash stock-based compensation expense 2,587 770 3,402 904 644 Merger and integration expense

  • 5,943

Settled share-based awards

  • 3,024
  • Other operating expense

1,435 1,333 157 935 (161) Income tax (benefit) expense 1,487 5,647 (5,149) 16,691 17,902 Interest expense 711 735 738 741 739 Depreciation, depletion and amortization 48,977 60,301 60,672 64,374 57,107 Accretion expense 202 248 241 216 128 Adjusted EBITDA $ 118,430 $ 119,716 $ 110,512 $ 123,848 $ 117,338 LQA Net Debt to Adjusted EBITDA 3Q19 Senior secured revolving credit facility $ 200,000 6.125% senior unsecured notes due 2024 600,000 6.375% senior unsecured notes due 2026 400,000 Total principal outstanding 1,200,000 LESS: Unrestricted cash (pro forma) (11,309) Net Debt 1,188,691 Adjusted EBITDA 117,338 LQA Adjusted EBITDA $ 469,352 LQA Net debt to Adjusted EBITDA 2.5 Discretionary Cash Flow Reconciliation 3Q18 4Q18 1Q19 2Q19 3Q19 Net cash provided by operating activities $ 116,036 $ 151,639 $ 74,559 $ 150,487 $ 113,692 Changes in working capital 347 (33,710) 33,864 (27,789) (2,803) Payments to settle asset retirement obligations 507 389 664 107 654 Payments for cash-settled restricted stock unit awards

  • 1,296

129

  • Discretionary cash flow

$ 116,890 $ 118,318 $ 110,383 $ 122,934 $ 111,543